Drilling system



Sept. 30, 1969 Original Filed Nov. 9, 1964 C. E. BANNISTER DRILLINGaYsTEM 2/ /7 o LE 3 Sheets-Sheet l /23 f /zz INVENTOR.

BY @MMT 719mm Sept- 30, 1969 c.E.BANN|s1'ER 3,469,499

DRILLING SYSTEM I5 Sheets-Sheet 2 Original Filed Nov. 9, 1964 ATTORNEYBf @MT 779mm' Sept. 30, 1969 c. E. eANNlsrER DRILLING SYSTEM OriginalFiled Nov. 9, 1964 5 Sheets-Sheet 5 C/j/a/e f. 5a/,wu few INVENTORUnited States Patent O 3,469,499 DRILLING SYSTEM Clyde E. Bannister,2727 Carolina Way, Houston, Tex. 77005 Original application Nov. 9,1964, Ser. No. 409,735, now Patent No. 3,381,766, dated May 7, 1968.Divided and this application July 31, 1967, Ser. No. 668,979

Int. Cl. F01c 1/00, 9/00 U.S. Cl. 91--58 6 Claims ABSTRACT OF THEDISCLOSURE This application is a division of application Ser. No.409,735, filed Nov. 9, 1964, now Patent No. 3,381,766.

The present invention relates to the field of subsurface exploration anddrilling systems utilized therefor, and more particularly to a systemespecially useful for drilling large holes in the earth.

One of the prior art drilling systems for oil exploration and recoveryand the like was the apparatus commonly termed a rotary rig. The rotaryrig included a derrick at the surface for suspending a drill string anda motor and mechanism for rotating the drill string to turn a bitattached at its far end. The cuttings were removed by a fluid sent downthe drill string and flowing back to the surface through the boreholeannulus, the space between the drill string and the borehole wall.

In many applications the fluid force or pressure was not sufficient toremove the cuttings as fast as necessary. The decrease in pressure wasmost evident when the hole size was increased, whereby the fluid flowedfrom a drill string having a relatively small opening into the vastexpanse of the borehole annulus.

One approach employed with some success for large holes was the reversecirculation technique. As described in the article 72-In. Holes AreBeing Drilled, by Robert G. Burke, in the May 4, 1964 issue of The Oiland Gas Journal, pages 71-73, the drillers utilized reverse-aircirculation in which air was pushed down the annulus of the borehole,across the bit face, and returned through the drill string. A very highcapacity compressor had to be used to develop even a relatively lowpressure and there still was circulation loss and inadequate fluid forceat times.

Recognizing the limitations of the prior art, I have invented a drillingsystem which is capable of maintaining a high fluid pressure to removethe cuttings rapidly and which does not require an extremely large fluidpump or compressor. My invention can be used to drill large holes, suchas the shafts required by the Atomic Energy Commission for undergroundnuclear explosions.

My invention is not limited to use with a rotary rig. In fact, Idisclose herein an embodiment of drilling apparatus that has theadvantages of high fluid pressure and minimum non-drilling time. Thisembodiment utilizes a bit driven by an oscillating motor to grind up thecuttings into pieces that can be removed easily. The oscillating icemotor is fluid actuated and I have provided a valve arrangement which isespecially advantageous where a high fluid pressure is controlled.

The above objects and advantages are obtainable with my invention,wherein the borehole annulus is not used as a conduit for the fluid and,instead, means is provided in the drill string, for example, to carrythe fluid into and out of the borehole. A seal is established adjacentthe bit to prevent the fluid from exiting through the borehole annulus.The cuttings are washed with a high pressure fluid carried down thedrill string -and the fluid and cuttings are carried up the drill stringby the fluid at high pressure to the surface.

ln one embodiment of my invention, a drilling system with an oscillatingbit can be provided with a seal adjacent the driving motor and flexiblehose can carry the fluid down to and out the depths of the borehole. Theoscillating bit grinds up the earth into very small pieces and thecuttings require only a small exhaust hose.

In connection with my invention, I have provided control means for theseal means, so that the drilling apparatus can be disposed freely in theborehole, and at a desired depth lthe seal means can be actuated fromthe surface to close off the Iborehole annulus. In one embodiment thefluid in the drilling apparatus actuates the seal means. The seal meansin one form can be an expandable means, such as a ring or tube aroundthe drilling apparatus which is inllated by a pressure generator. Thepressure generator can be disposed in the drilling apparatus, actuatedby the fluid pressure to produce an even greater pressure for inflatingthe tube. The control means can selectively actuate the seal means toestablish or release the seal. The drilling can continue with the sealestablished and moving forward with the drilling apparatus.

My improved valve for a fluid motor or other devices receiving a highpressure is arranged to minimize the antiunseating fluid force. A reliefhole is provided in the valve closure member and a closure means isprovided for the relief hole. The closure means is removed prior tounseating the valve closure member to relieve the fluid pressure. Inaccordance with my invention, a valve also can be jarred prior tounseating to eliminate sticking. In an embodiment with a valve rod, thevalve closure member can be freely mounted thereon and the valve rod canhave an engaging means spaced from the valve closure member to move agiven distance with the valve rod before striking the valve closuremember.

These and other objects of my invention are illustrated by severalpreferred embodiments to be described with reference to the drawings,wherein FIG. 1 is an elevation view, partially in section, showing oneembodiment of a drilling system in accordance with my invention.

FIG. 2 shows in more detail one form of pneumatic control means foroperating the seal means of the drilling system shown in FIG. l or ofother drilling systems.

FIG. 3 is a horizontal section along the lines 3 3 of FIG. 1.

FIG. 4 is an enlarged view of one form of sealing means for the drillingsystem of FIG. l or other drilling systems.

FIG. 5 is an elevation view in section of a fluid motor equipped with myimproved valve.

FIG. 6 is an enlarged elevation view, partially sectioned, of the valveshown in FIG. 5.

FIG. 7 is an elevation view, partially sectioned, of another form ofdrilling apparatus in accordance with my invention.

FIG. 8 is an elev-ation view, partially in section, of a rotary rigarranged in accordance with my invention.

FIG. 9 is a horizontal section along the lines 9-9 of FIG. 8, showingthe internal arrangement of a drill pipe.

FIG. l0 is a horizontal section along the lines 10-10 of FIG. 8, showingthe internal arrangement of a drill collar.

A description of several preferred embodiments of my invention followsnext. It will be obvious to one skilled in the art, after reading mydescription, that other apparatus is equally capable of using myinvention and that changes and modifications in the disclosed apparatusembodiments can be made without departing from my invention.

A drilling system in accordance with my invention 1s capable of drillinglarge holes, such as a hole or boreholes 1 (FIG. 1). Borehole 1 may beas large as six feet in diameter. One possible way of drilling borehole1 would be to use conventional drilling equipment, such as a rotary rigor oscillating drill system. With a rotary rig, a bit would be supportedin borehole 1 by the drill string and rotated in one directiontherewith. The cuttings would be removed by fluid ilowing down the drillstring and out the borehole annulus. But if the iluid must expand into alarge volume of the borehole annulus, the fluid pressure drops and thecuttings are not washed away rapidly enough. Reversing the lluid flowroute, into the borehole through the borehole annulus and out the drillstring, requires a very large capacity pump and the fluid pressure orvelocity is not always suflicient to remove large cuttings.

I have shown in FIG. l a drilling apparatus 2 capable of operating inlarge borehole 1 with a high fluid velocity. In general, fluid iscarried into borehole 1 by conduit means in drilling apparatus 2 and abit 3, disposed at the end of the drill apparatus 2, is rotated toremove portions or cutting from the borehole bottom 4. The fluid washesthe cuttings out of the borehole through another conduit means in thedrilling apparatus 2 at a high pressure. The exhaust conduit means takesthe place of the borehole annulus and has the advantage of a constant,relatively small but adequate size, irrespective of the borehole size,to maintain a high lluid pressure.

To prevent the Huid from exiting through the borehole annulus 6, Iprovide a seal means 5 adjacent bit 3 which substantially closes offborehole annulus 6. Seal means 5 is operated selectively by a controlmeans to open or close of annulus 6 at will. Drilling can continue Whileborehole annulus 6 is closed to penetrate further into the earth 7.

The particular form of drilling apparatus shown in FIG. 1 utilizes anoscillating, fluid actuated motor 8 mounted in a cylindrical housing 9.Motor 8 can be of several types, such as the improved motor disclosed inmy U.S. Patent 3,183,787 copending application, Ser. No. 265,839. Fluidenters housing 9 through a ilexible inlet hose 10 and is coupled tomotor 8 to sustain oscillating movement of an impeller blade coupled todrive shaft 11. The oscillating movement is coupled to bit 3 throughclutch 12 and an intermediate shaft 13 threaded at one end to engage bit3 and mounted for rotational movement in bearing 21. Fluid leaves motor8 within the cylindrical skirt 300 of motor casing 302 and passesthrough a central passage 14 in intermediate shaft 13, through anopening 15 in bit 3 to wash the borehole bottom 4 and cutting. When anelectric oscillating motor is used instead of a lluid motor, inlet hoseis coupled directly to bit opening 15 by suitable means.

The washed cuttings are picked up by the fluid and flow around bit 3into housing 9, in the direction of arrows 16. Motor 8 is suspended inhousing 9 from arms 17, resembling a spider (as best shown in FIG. 3),so that the iluid and cuttings can travel between the inside of housing9 and the outside of motor casing 302 to the entrance of a. flexibleexhaust hose 18, in the direction indicated by arrows 19. Exhaust hose18 is fastened to a shelf 20 of housing 9. Shelf 20 prevents the fluidfrom passing further along housing 9, forcing the fluid into exhausthose 18. Exhaust hose 18 conveys the fluid and cuttings to the surfaceand the drilling operations continues, supplied by a continuous amountof fluid in inlet hose 10.

Bit 3 can have a diamond cutting edge and its oscillating motion grindsborehole bottom 4, so that the cuttings are relatively small and can becarried through a small exhaust hose.

Drilling apparatus 2 is arranged further for continuous drilling byhaving one or more weighted sections 22, generally referred to asinertia barrels, to maintain the load on bit 3 necessary for maximumcutting effect. Sections 22 are attached to housing 9, preferably by aremovable coupling, such as tool joint (not shown). Inlet hose 10 andoutlet hose 18 pass through sections 22 and are provided with reels 23and 24, respectively, for storing sufiicient hose length to lower bit 3to a desired maximum depth. The fluid entering inlet hose 10 is at ahigh pressure, because a pump 25 is connected intermediate fluidcouplings 26 and 27. Fluid enters coupling 27 from a reservoir (notshown) at a low pressure and the pressure is increased in the pumpoutput to coupling 26 which is connected to inlet hose 10. The elongatedstructure of housing 9 and sections 22 is suspended in borehole 1 by acable 28 attached at one end to the end section 22 and at the other endto a reel 29. Cable 28 takes the load olf inlet hose 10 and exhaust hose18 and the cable reel 29 is attached to a drive mechanism (not shown) toraise and lower bit 3 at will.

Cable 28 is provided with insulated electric conductors (not shown) thatare used for a purpose to be described and these conductors areconnected to electric lines 30, 31 and 32, respectively, through acommutator assembly 33 on reel 29.

The seal means can take several forms to carry out its function ofsubstantially sealing off the borehole annulus 6. The sealing mechanismcan be an extendable member inserted between the borehole wall and thedrilling apparatus that circumfeerntially engages the borehole wall anddrilling apparatus, or knifes into the borehole wall to seal offborehole annulus 6. Another arrangement is to have the seal means formedby pivotally mounted sections of an annular plate that is forced intoengagement with the borehole wall and the drilling apparatus. Theseembodiments do not normally have freedom of axial movement in borehole1, which is desirable, although not essential, and the seal means has tobe retracted to move drilling apparatus 2 any appreciable distance. Forthis reason I have illustrated an embodiment that substantially sealsoff the borehole annulus `6 and allows for at least some axial movementin borehole 1 to have continuous drilling without adjusting the sealmeans. It is apparent that other forms of seal means can perform thesefunctions.

Seal means 5 is supported at the end of housing 9 adjacent bit 3. Thelluid and cuttings can enter housing 9 but they cannot go very far intothe borehole annulus 6, because seal means 5, when.closed, presents asubstantially complete lluid lock between housing 9 and the boreholewall. The seal or lluid lock is formed by an inllatable tube 35 (FIG.4), constructed of rubber or other elastic, fluid containing material,that rings or circumferentially surrounds and lits in a recess ofhousing 9.

Tube 35 has a rectangular vertical cross-section when deflated, one ofits longer sides 37 lying against a flat annular face 38 of housing 9and one of its smaller sides 36 lying against another flat annular face39 of housing 9. The other smaller side 40 lies against a flat annularface 41 of a ring 42 having an internal thread that engages a threadedend 43 of housing 9. Ring 42 can be unscrewed to remove tube 35. Theother longer side of tube 35, generally termed the shoe, has its outerface 44 substantially even with the outer face of housing 9 when tube 35is deflated. Adjacent ring 42, the corner of tube 35, where the fluidfirst hits, has a projection 45 that is beveled towards the boreholewall so that the fluid will tend to increase the pressure of shoe face44 against the borehole wall. When tube 35 is deflated, as shown in FIG.4, projection 35 rests against a matching beveled face 46 of ring 49.Tube 35 has an annular central cavity 47.

One of the support arms 17 for motor 9 (FIG. 3) is larger than the othersupport arm 17 to allow space for a passage 50 extending between housingface 38 and a surface 51 of support arm 17. Tube 35 has inlet extension55 constructed of the same material as tube 35 that lies in passage 50and has a metal, externally threaded, open end piece 56 projecting abovesupport arm surface 51. End piece 56 has a nut 57 firmly securing tubeinlet extension 55 in support arm 17. Secured to support arm 17 in uidtight relation by fasteners or welding (not shown) is a valve 80 havinga housing 59 with a chamber 60 in which tube end piece 56 extends and asecond chamber 61 communicating with chamber 60 by a passage 62. Passage62 has a poppet valve closure member 63 that seats with the uid, biasedclosed by coil spring 305, and is opened by an electromagnet 64 whenenergized by a current through electromagnet coil having terminal leads65 and 66. Chamber 61 has an internally threaded aperture that iscoupled to an externally threaded end of pipe 67.

The operation of seal means 5, without reference at this point toanything more than the simplest control means, can be pictured by firstassuming that tube 35 is dellated, las shown in FIG. 4, with a captive,imcompressible uid 4S in the tube cavity 47, tube inlet extension 55,and chambers 60 and l61. Valve 80 is opened by energizing elecuomagnet64, withdrawing poppet valve closure member 63. If there is no pressurein pipe 6'7 nothing will happen. As pressure is built up in line 67,tube 35 expands because of the increased pressure in tube cavity 47. Theonly way tube 35 can expand is at the shoe face 44 and as pressureincreases further shoe face 44 engages the borehole wall completelyaround housing 9 and over a substantial face area. The new shape of tube3S is represented by dotted lines 71. The iluid and cuttings aredeflected by tube side 40 and projection 45 and the borehole annulus 6is substantially sealed oil. Once tube 35 is expanded, electromagnet 64can be de-energized, closing valve 80, and tube 35 will remain inflated.

yThe pressure in pipe 67 that inates tube 35 can come from many sourcesdisposed at a number of locations. For example, the pressure can becontrolled by a pressure generator at the surface coupled to pipe 65.The pressure in pipe 67 can be decreased after poppet valve 80 is closedto allow tube 35 to deflate a predetermined amount whenever valve 80 isopened, as may be desirable momentarily to move bit 3 in or out of-borehole 1. Normally, housing 9 and sections 22 move further intoborehole 1 with tube 35 inflated and maintaining a substantial ilu-idlock -as the drilling continues.

The pressure in pipe 67 that inilates tube 35 is preferably provided bya pressure source mounted on drilling apparatus 2. The pressure sourcethereby need not transmit the high fluid pressure required to inflatetube 35 over a long distance. In my preferred embodiment, a pressuretransmitter 100 (FIG. 2) is mounted in housing 9 on the other side ofshelf 20 from where the iluid and cuttings flow. Pipe 67 passes throughshelf 20 in a fluid tight seal (not shown), in the same manner as inlethose 10, and is connected to a high pressure port 101 in a transmitterhousing. One end of the transmitter housing is a cylinder 102 thatreceives a slidable piston having a head 103 and connecting rod 104 toform a pressure generator. Piston head 103 has means for providing aslidable uid seal against the wall of cylinder 102, such as O-ring 105.The volume in front of piston head 103 and pipe 67 contains captive,incompressible fluid 48, that is placed under pressure as piston head103 moves towards housing port 101.

Connecting rod 104 can be manipulated by any suitable means to controlthe pressure in pipe 67. For example, an electromagnet or reversiblemotor can be used. I have illustrated a more sophisticated mechanismwhich does not require an electric power source, except to energize twovalves, and can be operated Without any electrical connection, ifdesired.

In my embodiment, pressure transmitter 100 includes a pressure operatedactuator formed by a cylinder 106, at the opposite housing end fromcylinder 102, and a piston head 107 having O-ring 10S. Piston head 107is attached to connecting rod 104 to move piston 103 and is biased inthe opposite direction from piston 103 by a coil spring 109 surroundingconnecting rod 104 and enaging a housing ledge 110 and the inner face ofpiston 107. In this arrangement, piston 107 normally is held againsthousing end 111 and is motivated in the opposite direction only by aforce created by permitting iluid from inlet hose 10 to pass throughcoupling 112, valve 113, and coupling 114 to a port 115 in housing end111. Valve 113 has two positions, electrically selected by a currentover electric line 116 (the two wires of a conventional electricallycontrolled valve are shown as one electric line for convenience). Oneposition, called position A, when valve 113 is energized, connectscoupling 114 to coupling 112 and the other position, called position B,connects coupling 114 to a vented coupling 117, open at its unconnectedend to the air in housing 9 above shelf 20. The volume on the oppositeside of piston 107 from port 115 is continuously vented to the air inhousing 9 above shelf 20 by a coupling 118 connected adjacent housingledge 110.

The operation of pressure transmitter 100 is controlled from the surfacewhere the fluid pressure in inlet 10 is generated and can be turned onor oil by control unit 120 energizing or stopping pump 25, respectively.The electric wires running to the electromagnet terminals 65 and 66 ofvalve 80 have been represented as a single electric line 121 in FIG. 2,for convenience, but in actual arrangement a two wire cable is used. Onewire from each of lines 116 and 121 can be tied together and connectedto one of the electric wires in cable 28, mentioned above, andultimately connected through commutator assembly 33 to line 30. Theother two wires, one from valve 113 and one for valve are individuallyconnected to separate wires in cable 28 and ultimately connected tolines 31 and 32, respectively. Line 30, being the common lead, isdirectly connected to one side of a power source 112, usually a DCsupply, and lines 31 and 32 are selectively coupled to the other side ofthe DC supply by separate switches 123 and 124 actuated at will, eitherindividually or together, by a control unit 120, the sequence dependingon the desired operation.

As the drilling apparatus 2 is lowered into borehole 1, pump 25 isdenergized and no fluid flows in inlet hose 10. Valves 80 and 113 aredeenergized (valve 113 is in position B, venting cylinder 106), and tube35 is deflated as shown `in FIG. 4. Piston 107 of pressure transmitter100 is held against housing end 111 by spring 109. Once the drillingposition is reached, control unit 120 energzes valves 113 and 80 byclosing switches 123 and 124, and pump 25 is energized to send a highpressure iluid down inlet hose 10. A part of the fluid ows into cylinder106 and acts against the face of piston 107 which is substantiallylarger than the face of piston 103, preferably at least four timeslarger.

The Huid pressure in inl-et hose 10 and entering cylinder 107 is nothigh enough to adequately inflate tube 35 and there is the furtherproblem of bleeding the iluid lines. Pressure transmitter serves toincrease the pressure and provides a uniform control with severalfurther advantages. Piston 107 is displaced by the uid pressure againstthe force of spring 109 and, because of the common connecting rod 104,piston is also displaced to increase the pressure of captive fluid 48 incylinder 102, pipe I67, and cavity 47. The increase in pressure withintube 35 causes shoe face 44 to extend and force against wall of borehole1 to substantially seal oi the borehole annulus 6. The smaller face areaof piston 103 produces a much greater force or pressure than thepressure acting on piston 107. It is apparent that tube 35 will not beinated until there is suicient pressure in inlet 10 to displace piston107. In other words, there is a predetermined pressure below whichpiston 107 will not be displaced and there is a predeterminedpressure-the normal pressure in inlet 10-which will displace itcompletely. The drilling system, including pressure transmitter 100, isdesigned so that the normal fluid pressure in inlet 10 is adequate toexpand tube 35 to the maximum expected borehole annulus spacing and tube35 expands laterally if the spacing is less than the maximum expected.

Once tube 35 is inflated to seal off borehole annulus 6, control unit120 is operated to de-energize valve 80, retaining the high pressure incavity 47. Valve 113 can be deenergized also, venting cylinder 106adjacent piston 107 to the air. Spring 109 forces out all the fluid incylinder 106 and pistons 107 and 103 return to their biased positions.The withdrawal of piston 103 reduces the pressure in pipe `67 to normal.Then valve 80 can be energized and tube 35 will deflate, opening theseal. The energizaton of valves 80 and 113 can be timed to permit atotal or partial deflation of tube 35. The partial deflation can be usedto free tube 35 should it happened to become stuck against a projectingpart of the borehole wall and it is not desired to completely releasethe seal.

The actuation of tube 35 need not require the use of valves or anyelectrical connection to the drilling apparatus 2. For example, controlof the fluid pressure in inlet 10 is sufficient to actuate selectivelytube 35. Assuming that valves 80 and 113 are not in the system, i.e. theconnections are as if each valve is energized, with fluid from inlet 10entering cylinder 106 and fluid from pipe 67 entering tube 35. When thefluid pressure is below a predetermined level, piston 107 will not bedisplaced. As the pressure is increased, piston displacement occurs andtube 35 is inflated at the normal pressure in inlet 10. To deflate tube35, the fluid pressure in inlet 10 is decreased, by turning pump 25 off,for example, and piston 107 returns to its biased position afterexpelling the fluid from cylinder 106.

Other forms of pressure transmitters can be employed to build up thepressure for inflating tube 35, and these pressure transmitters can becontrolled in several ways to close or open the seal.

As mentioned above, my invention can be applied to a rotary rig, such asrotary rig 130 shown in FIGS. 8-10 with a few modifications of existingequipment. The conventional derrick 131 (only partially shown) islocated above borehole 1 and includes platform 132. The drill string 133is composed of modified drill pipes 134 and modified drill collars 135.

Drill pipe 134 (FIG. 9), including kelly joint 134', has two conduits136 and 137, for the inlet fluid and outlet fluid, respectively, formedby the tubular body wall and an axially extending partition 138 securedtherein. Partition 138 extends into the tool joints on each drill pipeand kelly joint 134', and, when drill pipes 134 and kelly joint 134 arecoupled tightly, two essentially continuous conduits are formed. Eachdrill collar 135 (FIG. 10) has two longitudinally extending andlaterally spaced holes 139 and 140 therethrough that line up, when drillcollars 135 are coupled together to provide two continuous conduits. Thetool joint between the end drill collar 135 and the end drill pipe 134provides a separate passage (not shown) connecting one of the conduitsin the drill collar 135 to a conduit in the drill pipe 134, and anotherpassage (not shown) connecting the other of the conduits in the drillcollar 135 to the other conduit in the drill pipe 134. The end drillcollar 135 is coupled to bit 141. The inlet fluid conduit in end drillcollar 135 is coupled to a central aperture in bit 141 and the exhaustconduit opens at the lower face adjacent bit 141. Fluid passes from theinlet conduit in end drill collar 135, through bit 141 and forces thecuttings into the exhaust conduit in end drill collar 135.

Drill string 133 is rotated by a kelly 142 and its associated engine(not shown). The fluid coupling 154 to the kelly joint 134 has a lowerportion that rotates with drill string 133 and an upper portion that isstationary. The rotatable joint, which can be similar to the couplingshown in my U.S. Patent 2,345,465, or other types, is connected throughconduits to the respective inlet and outlet conduits of kelly joint134'. Coupling 154 connects the inlet conduit of kelly joint 134 toinlet hose 150 carried by a swiveled pay-out block 152 suspended byderrick 131. Hose 150 is connected to the fluid pump 153. The exhaustconduit in kelly joint 134 is connected by fluid coupling 154 to exhausthose 155 also carried by pay-out block 152 and connected to a fluidreservoir (not shown).

The drilling operation for rotary rig 130 follows the conventionalprocedures, except for the use of seal means 5 supported adjacent bit141 on end drill collar 135. The mechanical details for seal means 5 canbe the same as described above. End drill collar 135 is arranged tomount tube 35 outside and pressure transmitter 100 inside which iscoupled to the inlet conduit. Valves and 113 need not be employed andpressure transmitter can be operated by controlling the fluid pressurein the inlet conduit, as described above. Alternately, when valves 80and 113 are incorporated, an electric cable can be layed in one of theconduits and a commutator assembly used adjacent coupling 154 to connecta control means 120 and power supply 122 in the manner described above.

Seal means 5 functions in the same manner on rotary rig to provide asubstantial fluid lock across the borehole annulus 6. Drill string 133moves further into borehole 1 as the drilling continues and seal 5permits this movement while still retaining the substantial fluid lock.

The drilling apparatus shown in FIG. l can be modified as shown in FIG.7 to include the added feature of retrieving a borehole core as thedrilling continues. The surface equipment is the same and the only majorchange is in the motor 9 and bit 3. Motor 9 is modified to the extentthat the solid drive shaft 11 is replaced by a hollow drive shaft and atube 176 extends over one end of drive shaft 175 and is mounted in axialalignment in housing 9. The other end of drive shaft 175 is coupledthrough a coupling 176 having a central opening that connects driveshaft 175 and the shaft end of a bit 178. Bit 178 has the conventionalcutting teeth 181, preferably diamond edge, and is mounted forrotational movement in bearing 179. The inlet fluid passes from motor 9through several passages 180 in bit 178, out the lower face of bit 178to wash the cuttings into the exhaust fluid path through housing 9.

Bit 178 further includes a rigid, axially aligned tube 182 projectingoutward from the cutting teeth 181 into borehole bottom 4. The far endof tube 182 has a cutting edge 183, preferably diamond studded, forcutting into the earth. In this manner the center of the borehole bottom4 is cored and not drilled. The center of the borehole 1 is the slowestsection drilled due to the slow movement of bit 178, so that noappreciable delay in drilling is produced. Tube 182 receives core 184.Core 184 passes through an axial opening in bit 178, into coupling 176,drill shaft 175 and into tube 176. Drive shaft 175 rotates freely withinthe end of tube 176, tube 176 being stationary and constituting a corestorage facility that can extend a substantial distance.

In drilling a large hole, the fluid motor for drilling apparatus 2 (FIG.l) must be of substantial size. One of the chief problems in enlarging afluid motor which has valve closure members that seat with the fluid, isunseating the valve closure members. A fluid motor like the onedescribed in my above referenced U.S. Patent 3,183,787 can be modifiedto facilitate valve unseating. The modification improves the motoroperation with a high pressure, continuously flowing fluid, decreasingthe chance of a stuck valve closure member. In general, I have provideda means for relieving the pressure against the valve closure member sothat the valve closure member can be opened more easily while notinhibiting the closing function. In another respect, I have providedactuator means that moves a distance before engaging the valve closuremember with a jar to dislodge a stuck valve closure member.

A preferred embodiment of a fluid motor 200 having these improvements,is shown in FIG. 5. Motor 200 is arranged in most respects like themotor described in my above referenced U.S. Patent 3,183,787 includingmotor casing 201, fluid inlet pipe 202, drive shaft 203 mounted inbearing 204, motor housing 205 with only the intake block 206 and partof the valve rod block 207 shown. The impeller blade (not shown) isdriven by the fluid entering the motor housing by manipulation of thevalve means 208 in the intake block and exhaust block (not shown), as isdescribed in my referenced U.S. Patent 3,183,787.

The valve means 208 includes intake poppet valve closure members 209 and210 and the exhaust poppet valves (not shown), each arranged in the sameunique fashion of my invention on their respective valve rods 211 and212 for seating with the fluid pressure in matching valve seats 213 and214, respectively. Valve rods 211 and 212 are supported and pass freelythrough spiders 215 and 216, respectively, in intake block 206 toprevent lateral movement.

Valve means 208 is manipulated by an actuator means 217 includingprojection means 218 on drive shaft 203 for oscillation therewith.Projections 218 operate a lost-motion spring-loaded actuator means 219that, in turn, shifts the linkage means 220 to open an intake valve onone side of the impellar blade (not shown) and the exhaust valve on theother side of the impellar blade, then opening the other intake andexhaust valves, and alternating this sequence with the oscillation ofdrive shaft 203. Linkage means 220 is also actuated by an auxiliaryvalve unseating means 221. All these mechanisms operate as described inmy above referenced U.S. Patent 3,183,789.

The modification in the valve means 208 that reduces sticking andfacilitates opening the valve closure member is best shown in FIG. 6 forpoppet valve closure member 209 and valve rod 211. Poppet valve closuremember 209 closes fluid passage 225 (FIG. seating with the fluid whenvalve rod 211 is in one position. A heavy pressure continues to keepvalve closure member 209 closed and when valve rod 211 is lifted by thelinkage means 217 a very large force is required to counter the fluidpressure.

I have provided in valve closure member 209 a central passage 226 that,when open, carries fluid from the face 227 of valve closure member 209into the motor housing through spider 215. When passage 226 is opened,pressure is relieved on valve closure member 209 and linkage means 217can unseat valve closure member 209 more easily. Passage 226 has apoppet valve seat 228 that receives a poppet valve closure member 229that slides freely on valve rod 211, has a smaller surface area facethan face 228 and seats with the fluid pressure. When valve rod 211 isin the position for valve closure member 209 to close, as shown in FIG.6, valve closure member 229 is seated also.

Valve rod 211 passes freely through a ring 235 supported in passage 226from valve closure member 209, by spaced arms v240 that permits fluidflow therearound. As linkage means 220 moves valve rod 211 to a secondposition, opening valve closure member 209, valve rod 211 has engagingmeans, such as collar 230l fixed thereto and spaced between and fromvalve closure member 229 and ring 235 that jars and unseats valveclosure member 229 to permit fluid to enter passage 209 and 225. Thepressure on valve closure member 209 being relieved, valve closuremember 209 is jarred and unseated by an engaging means, such as a collar231 fixed to valve rod\211 and spaced from ring 235 on the opposite sidefrom collar 230. The spacing is sufficient to develop a forceful jar. Aslong as valve rod 211 is in the second position, valve closure member209 remains unseated.

The arrangement of engaging means and valve rod can take other forms tounseat a relief valve closure member first. Other arrangements of avalve rod and valve closure member can be used to provide a jar at acentral location to prevent valve sticking. These features, eithertogether or individually, can be utilized in other devices where valvesare employed and for many types of valves.

While I have disclosed several preferred embodiments of my invention,other embodiments could Ibe illustrated and are obvious to one skilledin the art.

I claim:

1. A fluid control valve, comprising,

valve seat means defining a first passage,

first valve closure means seating with the fluid pressure into the valvefor closing said first passage,

said first valve closure means having a second passage to permit thefluid coming into said valve to flow into said first passage with saidfirst valve closure means seated,

second valve closure means for closing said second passage,

means for successively jarring and unseating said second valve closuremeans from said second passage and unseating said first valve closuremeans from said first passage to facilitate opening of the valve evenwhen `fluid is flowing into said valve.

2. Apparatus, as described in claim 1, wherein,

said first valve closure means is a removable first member that engagesa valve seat to close off said first passage,

said second passage being a hole in said member,

said second closure means is a removable second member for closing offsaid member hole and seating with the fluid flowing into the valve,

said second member having a hole extending in line with the direction ofmovement of said second member, said removing means including a valverod extending freely through said second member hole and said firstmember hole and having a first engaging means arranged, when said firstand second members are seated and upon movement of said valve rod, tounseat successively said second member and said first member to releasepressure on said first member.

3. Apparatus, as described in claim 2, wherein,

said engaging means includes spaced first and second abutments,

said first abutment being closest to said second member and, uponmovement of said valve rod in the opposite direction from fluid flow,jarring and carrying said second member in said opposite direction toopen said second member hole and permit a portion of the fluid to entersaid first passage and thereafter said second abutment jarring andcarrying said first member in said direction to fully open said firstpassage to said fluid.

4. In combination with a fluid actuated motor having at least first andsecond inlet passages and first and second valve closure members forsaid respective first and second inlet passages that each seat with thefluid pressure, separate from a respective seat by movement ofrespective valve rods, and open and close to permit said fluid to flowalternately into said fluid motor through said first and secondpassages, the improvement comprising,

each of said valve rods extending through a hole in said respectivevalve closure member for free movement in the direction of unseating andhaving means on the opposite side of said respective valve closuremember from the side said respective valve closure member unseats forengaging said valve closure member said means being arranged to engagesaid respective valve closure member after a given distance of freemovement of said respective valve rod, to jar said respective valveclosure member prior to unseating and unseat said respective valveclosure member as said respective valve rod moves further in thedirection of unseating,

each of said valve closure members comprising a removable irst memberthat closes off said respective inlet passage,

said first removable member having a hole,

a removable second member for closing off said first member hole andseating with said fluid flowing into said motor, said second removablemember havin-g a hole extending in line with the direction of movementof said removable second member,

said respective valve rod extending freely through said second memberhole and said rst member hole,

said engaging means comprising on each of said valve rods first andsecond abutments spaced apart along the length of said respective valverod, said first abutment being closest to said second member and, uponmovement of said respective valve rod in the opposite direction fromsaid fluid flow, jarring and carrying said second removable member, insaid opposite direction to open said second removable member hole andpermit a portion of the fluid to enter said respective inlet passage,and thereafter said second abutment jarring and carrying said firstremovable member in said opposite direction to fully said respectiveinlet passage to said fluid.

5. A fluid control valve, comprising,

valve seat means defining a first passage,

first valve closure means seating with the fluid pressure into saidvalve for closing said first passage, said first valve closure meanscomprising a removable first member that engages a valve seat to closeoff said first passage, said first valve closure means having a secondpassage to permit the fluid coming into said valve to flow into saidfirst passage with said rst valve closure means seated, said secondpassage comprising a hole in said member,

second valve closure means for closing said second passage,

said second valve closure means comprising a removable second member forclosing off said second passage hole and seating with the fluid flowinginto said valve, said removable second member having a hole extending inline with the direction of movement of said second member,

means for successively unseating said second valve closure means fromsaid second passage and said first valve closure means from said secondpassage, said unseating means including a valve rod extending freelythrough said removable second member and having a first abutment closestto said second removable member, and a second abutment spaced from saidfirst abutment on the opposite side of said first abutment from saidsecond member, and upon movement of said valve rod in the oppositedirection from said fluid flow, jarring and carrying said second memberin said opposite direction to open said second member hole and permit aportion of said fluid to enter said valve and thereafter furthermovement of said valve rod in said opposite direction, said secondabutment jarring and carrying said first member in said oppositedirection to open fully said first passage to said fluid.

6. In combination with a fluid activated motor having at least one valveclosure member that seats with the fluid pressure and is separated fromthe seat by movement of a valve rod, the improvement comprising,

said valve rod extending through a hole in said valve closure member forfree movement in the direction of unseating and having means on theopposite side of the valve closure member from the side said valve`closure member unseats for engaging said valve closure member, saidmeans being arranged to engage said valve closure member after a givendistance of free movement of said valve rod, to jar said valve closuremember prior to unseating and unseat said valve closure member as saidvalve rod moves further in the direction of unseating,

said valve rod being supported for free movement through a spiderdisposed between said engaging means and a second engaging means on saidvalve rod,

said spider being part of a second valve closure member that seats withsaid fluid,

said second engaging means being arranged to unseat said second valveclosure member after said one valve closure member is jarred andunseated.

References Cited UNITED STATES PATENTS EVERETI A. POWELL, JR., PrimaryExaminer U.S. Cl. X.R.

